DEVELOPMENT AND IDENTIFICATION OF PETROPHY SICAL ROCK

TYPING FOR EFFECTIVE RESERVOIR CHARACTERIZATION

BIOR ATEM BIOR BARACH

A dissertation submitted in partial fulfilment of

the requirements for the award of the degree of

Master of Petroleum Engineering

School of Chemical and Energy Engineering Faculty of Engineering

Universiti Teknologi Malaysia

MAY 2019

i

DEDICATION

This Thesis work is dedicated to my dear wife, for her unconditional love and

support.

To my lovely sons and daughters, for the joy they gave me in overcoming the hard

times.

To my beloved parents and siblings, for continuously encouraging me to explore new

areas.

To my supportive parents-in-law, for their deep love and care of my family.

iv

ACKNOWLEDGEMENT

First, I would like to express my greatest appreciation and respect to my

supervisor, Associate Professor Ir. Dr. Mohd Zaidi Bin Jaafar for his advice and

guidance during the course of this research. His enthusiasm and humour made these

years at Universiti Teknologi Malaysia (UTM) enjoyable.

My appreciation goes to Professor Dr. Ariffin Samsuri, Associate Professor Dr.

Muhammad A. Manan and Associate Professor Dr. Issham B. Ismail of UTM, who

generously accepted to be members of my thesis committee and all made significant

contribution to this work. Their continuous and constructive critiques and suggestions

have helped me a lot to improve this work.

Special thanks go to the School of Chemical and Energy Engineering,

Department of Petroleum Engineering for their support including the time to share

their knowledge with me.

My profound gratitude is expended to my family; my wife and my children for their

constant support (morally and emotionally) and encouragement to move forward

through both good and bad times.

I am also very grateful to my Course-mates; Abdul Hakim, Azureen Alya, Siti

Rodhiah, Buwaneswari Nagayan, Ahmad Fikri and Mohd Fahmi for providing a

friendly environment and helpful discussions during the past two years.

Most importantly, I would like to express my sincere gratefulness to my friends

and brothers. Andrew Ariik Arok and Peter Mayom Kuir, who have been a blessing to

me and family. I live thousands of miles away from them, but I have always counted

on their emotional support guided by our principles of understanding, trust and

wholehearted encouragement we have been showering one another. Every minute

spend with these guys is often both meaningful and impactful.

v

ABSTRACT

Rock typing is an essential tool used to distribute reservoir rock and fluid

properties in reservoir models. It provides more accurate estimates of oil reserves

during field studies and prediction of reservoir performance. These properties are

required inputs for static and dynamic models to populate porosity, permeability, and

shale volume which influence reservoir productivity. During field development studies

(FDP), the technical main aim is to design a fit for purpose project within budget to

produce commercial volume of hydrocarbons in the field and reduce residual oil in the

reservoirs. However, geomodellers frequently faced challenges in integrating

geological facies with rock characteristics and fluid flow to predict petrophysical

properties due to limited correlation between geological features and engineering

concepts. This thesis examined Petrophysics rock types based rock classification

scheme by comparing the approaches using rock samples. Among the trimmed

approaches are Hydraulic Flow Unit(HFU), Global Hydraulic Elements(GHE),

Winland R35, Pore Geometry Structure (PGS). Also presented is the use of electrical

and nuclear log data obtained from the well Neutron-Density to produce relationships

that tie pore geometric attributes, pore structures, and hydraulic flow characteristics.

The study selected Hydraulic Units and GHE methods among others to be robust in

Rock Typing based on consistencies observed between porosity and permeability

relationships in typical clastics reservoirs. Thus, it reduces the uncertainties in

reservoir models. Using capillary data to derive saturation height functions, the

Hydraulic units demonstrated consistent results of rock types that integrates geological

description with engineering hydraulic features.

vi

ABSTRAK

Pengkelasan batuan adalah satu keperluan untuk mengagihkan jenis atau kelas

batuan dalam model takungan. Ini akan membantu anggaran simpanan minyak dan

ramalan pencapaian takungan dengan lebih tepat. Jenis batuan berkait rapat dengan

sifat takungan seperti keliangan, keterlapan, jumlah shale dan semua ini

mempengaruhi pengeluaran sesebuah takungan. Semasa kajian pembangunan

takungan, tujuan utama ialah untuk membuat proj ek yang memenuhi kehendak optima

ekonomi. Tetapi ahli model kajibumi sering berhadapan dengan masalah mengabung

data geologi, sifat batu batuan, keboleh aliran, sifat petrofizik disebabkan kurang

pemahaman di antara sifat geologi and konsep kejuruteraan. Thesis ini mengkaji skim

pengkelasan batuan berlandaskan Petrofizik dengan membandingkan pendekatan yang

menggunakan sampel batuan. Antara pendekatan yang dikaji ialah Unit Aliran

Hidraulik, Elemen Hidraulik Sejagat, Kaedah Winland R35 dan Struktur Geomteri

Liang. Turut dikajikan ialah pengunaan data berlandaskan elektrik dan nuklear yang

didapati dari telaga, dan mengaitkan hubungan antara skim ini dengan tujuan

memahami hubungan antara asas geometri, struktur keliangan dan sifat aliran

hidraulik. Kajin ini memilih Unit Aliran Hidraulik, dan Elemen Hidraulik Sejagat

sebagai skim pengkelasan yang sesuai digunakan dalam takungan jenis batuan klastik

berdasarkan hubungan yang konsisten dianatara keliangan dan kebolehaliran. Oleh itu

ia boleh menggurangkan ketidakpastian dalam model takungan. Menbanding

keputusan ketepuan dari model kapilariti dan Unit Aliran Hidraulik, ia menunjukkan

keputusan yang seragam atau konsisten, membolehkan teknik ini boleh dipercayai. Ini

menunjukkan ia mampu menggabung asas geologi dan sifat kejuruteraan

vii

TABLE OF CONTENT

DECLARATION.......................................................................................................iii

DEDICATION...........................................................................................................iv

ACKNOWLEDGEMENT..........................................................................................v

ABSTRAK.................................................................................................................vi

ABSTRACT............................................................................................................. vii

LIST OF ABBREVIATIONS..................................................................................xiii

CHAPTER 1............................................................................................................... 1

1. INTRODUCTION.............................................................................................1

1.1. Background............................................................................................ 1

1.2. Problem Statement.................................................................................3

1.3. Objectives..............................................................................................3

1.4. Hypotheses...........................................................................................4

1.5. Research Scope..................................................................................... 4

1.6. Significance of Study............................................................................. 5

1.7. Thesis Summary.....................................................................................6

CHAPTER 2............................................................................................................... 9

2. LITERATURE REVIEW................................................................................. 9

2.1. Reservoir Characterization.....................................................................9

2.1.1. Hydraulic Flow Unit (HFU) 9

2.1.2. Global Hydraulic Elements(GHE) 14

2.1.3. Winland R35 Method 15

2.1.4. Pore Geometry Structure (PGS) 20

2.1.5. Jennings and Lucia - Reservoir Fabric Number(RFN) 21

2.1.6. Log-Based Rock Typing Approach (Electrofacies) 23

2.2. Capillary Pressure and J-Function using SCAL data............................25

2.3. Pore Throat Size and Distribution Effect ............................................ 26

CHAPTER 3..............................................................................................................29

3. METHODOLOGY........................................................................................ 29

3.1. Introduction to the Methods of Rock Typing....................................... 29

3.2. Methods and Work Flows....................................................................30

3.2.1. Routine Core Routine Rock Properties Core Analysis Data 30

3.2.2. Special Core Properties Core Data Analysis 30

viii

3.2.3. Geological Facies 31

3.2.4. Petrophysical Rock Typing using Hydraulic Flow Unit 31

3.2.5. Petrophysical Rock Typing using Electrofacies 32

1.1. Project Progress ................................................................................. 36

CHAPTER 4..............................................................................................................37

4. RESULTS ..................................................................................................... 37

4.1. Discussion of Results..........................................................................37

4.2. Core- Based Rock Typing and Validation ......................................... 37

4.2.1. Lithofacies from core using Geological Aspect 38

4.2.2. SEM -XRD Analysis 39

4.3. Permeability ....................................................................................... 41

4.3.1. Permeability Prediction from Capillary Pressure 42

4.3.2. Hydraulic Flow Unit(HFU) Method 44

4.3.3. Global Hydraulic Elements(GHE) Method 47

4.3.4. Interrelation between Pore Geometry, Geological Facies and

Flow Units 49

4.3.5. Winland R35 Method 51

4.3.6. Log-Based Rock Classification using Neutron-Density 53

4.4. Lithofacies and Electrofacies comparison ......................................... 55

4.5. Capillary Pressure from Core data ..................................................... 57

4.5.1. Water Saturation Height Modelling 60

4.5.2. Irreducible Water Saturation 64

4.6. Integrating Flow units into Saturation-Height Modelling...................64

4.7. Review of Functions, Guidelines, Conversion and Corrections used. 66

4.7.1. Core-Based Function Characteristics 66

4.7.2. Log-Based Functions Characteristics 66

4.7.3. Guidelines for Saturation Height Function Selection 67

4.7.4. Conversion from Laboratory to Reservoir Conditions 68

4.7.5. Stress Corrections 69

4.7.6. Choice of functional form and degrees of freedom 71

CHAPTER 5.............................................................................................................. 73

5. CONCLUSION ............................................................................................. 73

5.1. Conclusion ......................................................................................... 73

5.2. Summary ............................................................................................ 74

5.3. Recommendations .............................................................................. 75

REFERENCES......................................................................................................... 76

APPENDIX .............................................................................................................. 83

ix

LIST OF FIGURES

Figure 2-1: HFU Method of Rock Typing (Merandy Palabiran,2016)......................12

Figure 2-2: Porosity vs Permeability for different HUs using A (Corbett et al,2004)13

Figure 2-3: GHE Rock Typing Approach(Corbett et al,2004)................................ 15

Figure 2-4: Winland R35 Rock Typing plot(Merandy et al,2016)........................... 17

Figure 2-5: MICP plot for pore size distribution(Semi-log plot)...............................18

Figure 2-6: PGS Approach from Rock Type Curve.................................................21

Figure 2-7: Jennings-Lucia Rock Typing Method..................................................23

Figure 2-8: Permeability Range from 1mD - 1D at same porosity value, Wanida(2016

.................................................................................................................................25

Figure 2-9: Tube model to represent Height above FWL on sturation profile.........27

Figure 3-1: Rock Typing using Geological and Petrophysical Data by Ebanks et al,(1987)..................................................................................................................34

Figure 3-2: Data Gathering and Research Work Flow.............................................. 35

Figure 3-3: Rock Typing Methods and J-Function Construction............................. 35

Figure 3-4: Gantt Chart for Master’s Project I and I I ...............................................36

Figure 4-1: Thin section and SEM photographs for different rock types................. 40

Figure 4-2: Core Permeability versus Core Porosity Pooled into 3 Lithofacies groups

.................................................................................................................................40

Figure 4-3: Core Permeability versus Core Porosity for pooled lithofacies.............. 42

Figure 4-4: Permeability versus Porosity pooled lithofacies from core data.............43

Figure 4-5: Probabilistic approach to rock typing using log(FZI)............................ 45

Figure 4-6: RQI versus PHIz for different HU identified from F Z I......................... 46

Figure 4-7: GHE Method of Rock Typing using Hydraulic Units............................ 48

Figure 4-8: Permeability ranges with Hydraulic Units.............................................50

Figure 4-9: Permeability ranges from Geological Facies.......................................... 51

Figure 4-10: Winland R35 Rock Typing Method....................................................52

x

Figure 4-11: Neutron-Density Rock Typing from well logs...................................... 54

Figure 4-12: Comparison between Lithofacies and Electrofaies............................... 56

Figure 4-13: Capillary Pressure Versus Brine Saturation......................................... 58

Figure 4-14: Capillary Pressure for Hydraulic Units 1 and 2 ........................... 59

Figure 4-15: Capillary Pressure for Hydraulic Units 2 and 3 ........................... 59

Figure 4-16: Capillary Pressure for Hydraulic units 2, 3, 4 and 5 .................... 60

Figure 4-17: J function - Normalized Water Saturation fit to core data from J, K & M

sands........................................................................................................................ 61

Figure 4-18: Swi vs Porosity by Lithofacies..............................................................62

Figure 4-19: Swi vs Porosity by Rock Quality.......................................................... 63

Figure 4-20: Saturation Height Functions according to HU 1, 2 and 3 ......................65

Figure C-1: GHE Method of Rock Typing using Hydraulic Units............................ 98

Figure D-2: Capillary Pressure data Groupings.....................................................102

xi

LIST OF TABLES

Table 2-1: Summarizing HU and GHE using FZI values..........................................14

Table 2-2: R35 values distribution for rock type classification(Merandy et al, 2016)

.................................................................................................................................. 17

Table 2-3: Empirical and Theoretical Petrophysical Rock Typing by Mirzaei-Paiaman

et al, (2018)...............................................................................................................28

Table 4-1: Permeability estimates for lithotype classes for SHF.............................. 43

Table 4-2: Statistical End Points of FZI used in determining H U ............................46

Table 4-3: FZI values for each HFU methods identified...........................................47

Table 4-4: FZI values for each HFU methods identified...........................................48

Table 4-5: R35 values according to pore size distribution.........................................52

Table 4-6: Petrophysical Rock Typing using Density-Neutron Logs........................ 55

Table 4-7: Lithofacies Color definition..................................................................... 57

Table 4-8: Saturation Height-Functions for rock types 1 to 3 ...................................66

xii

LIST OF ABBREVIATIONS

PRT Petrophysical Rock Typing

PTR Pore Throat Radius

RCA Routine Core Analysis

SEM Scanning Electron Micrograph

SCAL Special Core Analysis

HFU Hydraulic Flow unit

RQI Reservoir quality index

Oz normalized porosity

FZI Flow Zone Indicator

MICP Mercury Injection Capillary Pressure

SHF Saturation Height Function

GHE Global Hydraulic Elements

PGS Pore Geometry Structure

K permeability

core perm core permeability

PHID density porosity

Sgv surface area per grain volume

9 porosity

CHAPTER 1

1. INTRODUCTION

1.1. Background

Reservoir characterization has always been a challenging domain in oil and gas

industry for a long time. There are many approaches and methodologies that are

applied with the aim of establishing statistically significant correlations between

reservoir storage and fluid flow characteristics. Ranking of obtained correlations and

their optimized clustering are used for rock typing that aims to derive representative

model equations for static modelling. However, selection and validation of these

methods of clustering the similarities still face hurdles due to complexities in pore-

space conditions and reservoir geometry. Petrophysicists need to adequately

understand these complexities in order to derive representative models for accurate

predictions of petrophysical characteristics, mainly, between fluid flow (permeability)

and reservoir storage (porosity) across the field.

It has become Industry standard to come up with Petrophysical Rock Types

that are used as inputs in saturation height models and in three dimensional (3D)

reservoir characterization models. The ultimate goal is for accurate initial water

saturation distribution, hydrocarbon volumes determination, fluid contacts

determination (hydrocarbon-water contacts), free water level confirmation and

evaluation of various uncertainties.

Integration of routine core analysis data, mineralogical studies such as XRD,

petrographical studies as thin-sections, SEM, CT-Scan, and pore geometry

information from SEM analysis are used to determine Petrophysical Rock Types

(PRTs). Other important information is obtained by incorporating Special Core

1

Analysis (SCAL) mercury injection capillary pressure (MICP or HPMI) data. In

complex lithologies, such as carbonate formation, NMR T2 distributions on water

saturated samples are valuable in detecting connected vugs, that will reveal large pore

body sizes in the absence of large pore throats on MICP. On the other hand, mercury

injection experiments are carried out on core samples, and the results are used to

determine pore-size-distributions for subject rocks. As for confirmation, the pore size

distributions obtained from RFT and core analyses are compared. The information on

pore-throat-size distribution, can only be used for rock typing when comparison

indicates appreciable agreement.

The most well-known petrophysical rock type characterization based on pore

throat radius indicators (PTRi) are: Winland, Pittman, Leverett k-PHI Ratio, Lucia

Rock Fabric Number (RFN), Flow Zone Indictors (FZI), Reservoir Quality Index

(RQI), and Aguilera. In this characterization, four rock properties to be studied are

Permeability, Lithology, Porosity and Lithofacies. It is imperative to note that none of

the standard Pore Throat Radius indicators (PTRi) directly account for multi-modal

pore geometries leading to poor representation and typing for complex reservoir rocks.

Static and dynamic models are mostly depending on reservoir energy through facies

classification that are driven by shape and pore geometry. The objective is to distribute

porosity, permeability, thickness and net-to-gross in three dimensions using various

mapping techniques provided that the similarity grouping (i.e. rock typing) is done

appropriately. However, distributing initial and irreducible water saturation remains

extremely challenging for reservoir engineers because of several factors such as

diagenesis that often affect flow characteristics which is therefore the cause of

volumetric reduction.

The ultimate goal of PRTs is to provide users with transforms for flow

characteristics and volumetric parameters that are important inputs for three

dimensional dynamic reservoir simulators and reservoir characterization software.

This thesis aims to study effects pore-throat-size-distribution in defining Petrophysical

Rock Typing by using both core and log data and enhance the relationship between

capillary properties, permeability and porosity correlations and hydraulic flow units.

2

1.2. Problem Statement

Clastic formations often have variation in rock properties as a function of

location. This rock character is termed as reservoir rock heterogeneity. It’s a property

of the reservoir rocks that has a huge impact on petroleum system modeling, formation

evaluation and reservoir simulations which are critical in maximizing production from

shaley reservoir sands. Static and dynamic models are incapable of modelling volume

of shale (silt and clay) due to this heterogeneity. In order to build a robust static and

dynamic reservoir models, it therefore becomes essential to come up with

Petrophysical Rock Types. These Petrophysical Rock Types act as the bases of relating

permeability and porosity to execute a successful drilling, production, injection,

reservoir studies and simulation models.

Rock Types give crucial insights on how pore size and pore throat size

distribution relates to saturation height models that helps in calculating saturation away

from well location in a 3D sense based on the established physics of buoyancy and

capillary pressure in a rock-fluid system. Also, a correlation between permeability and

porosity can be established to distinguish reservoirs based on rock quality. In such

correlations, we expect to see small pore-throat size represents poorer rocks and large

pore-throat-size indicates better rock quality. Armed with these valuable informations,

the team can characterize formations that may contain large amount of hydrocarbons

but not commercial due to low permeability across the field. This study will provide

essential tools to recommend suitable approach to recover these hydrocarbons.

1.3. Objectives

The main of this thesis is to integrate core data and well logs to enhance

reservoir characterization through reservoir rocks classification in a geologically and

petrophysically consistent manner. The main objective is to investigate scientific

3

approaches of utilizing rock data at different time and length scales to describe

reservoir rock-fluid systems consistent.

a. To determine Petrophysical Rock Types through quantitative methods

that derive pore-sized distribution functions from MICP data to

characterize complex pore system.

b. To integrate multiple pore system attributes defined in (a) to detect

petrophysical variation between pore systems that improves

petrophysical ranking of rock types.

c. To recommend the best petrophysical rock typing approach that reflects

coherency in saturation height functions (consistency in J-Function).

1.4. Hypotheses

a. Pore Throat Size distribution relate pore geometry to reservoir properties

(Controls of conduit size for effective fluid flow). Small Pore Throat

Radius indicates poor quality rock.

b. Petrophysical Rock Typing provides more accurate reservoir

characterization to minimize errors in reserves estimation.

c. Provide important insights to recommend proper development strategies

to produce economical amount of hydrocarbons in particular formations to

reduce residual oil.

1.5. Research Scope

Conventional and Special Core analysis data will be used to calibrate well log

data. Capillary pressure curves(from MICP data) will be used to distinguish

4

Petrophysical Rock Types into poor and good quality rock as a function of Pore Throat

Radius.

Scope 1: Characterizing PRTs using core description

a. Petrographic analysis (Mineralogical study such as XRD, thin section,

SEM and CT-scan)

b. Establishing relationship between pore geometry and pore size

distribution using core description and analysis (lab measurement- MICP)

i. Using RQI/FZI equations

ii. Poro-perm transform to predict permeability away from well

location.

Scope 2: Integrating lithofacies from core data with log characters to group rocks into:

a. Rocks with similar flow behavior and rocks with same reservoir storage

b. Selecting rock with similar geological attributes to relate rocks-fluid

interactions

Scope 3: Using Special Core Analysis to construct Cap Pressure curves and construct

SHF according to:

a. Cluster rocks that exhibit similar fluid flow behavior

b. Determine consistency in J-Function curves for a given saturation (Sw)

for any height above free water level in reservoir

c. Comparing the permeability generated from other empirical equations

with log derived permeability to recommend a suitable approach for

clastic formations in Sabah fields.

1.6. Significance of Study

Modern volumetric estimation approach requires petrophysical rock typing

which are controlled by porosity and permeability. Each rock type represents

5

distinctive pore geometry/morphology that signifies specific pore throat size

distributions. For a particular rock type there is a single saturation height function that

exhibits a certain set porosity and permeability is constructed.

Although pore throat radius is not the only thing, but one of the controls of

permeability since it shapes up the conduit size for the flow. Permeability has no direct

downhole measurement other than complex and lengthy pressure testing and flow

measurements because it is a dynamic reservoir property. Permeability controls fluid

flow because it is a function of the rock’s microscopic properties such as pore size,

grain sorting, tortuosity, cementation, and compaction. If pore throat radius

distributions derived from mercury injection are similar, the rock pore geometry shows

similar trends. These trends are characteristics of permeability which is intrinsic

hydraulic property that control fluid flow. High permeability rocks result in high

production rate as a function of pressure drop during drawdown.

Thus, it would be of great advantage if the most of reservoirs parameters can

be predicted within great certainty. This project will therefore, assist in:

a. Providing accurate reservoir characterisation by assigning representative

Petrophysical parameters for hydrocarbons volumetric calculations.

b. Establishing appropriate correlation to predict fluid flow characteristics far

away from well location in a field wide.

c. Recommend proper development strategies to produce economical amount

of hydrocarbons in these particular formations to reduce residual oil.

1.7. Thesis Summary

This project will be organized by covering the sections summarized below:

a. Sufficient, for data acquisition and analysis on each procedures & compilation

b. No equipment or lab experiment needed

6

c. Using Capillary Pressure data to established the relationship between PRTs and

PTR

d. Sufficient research SPE papers/journals: One petro website

e. Reference from industry standards, books & manual available.

7

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